US20110297398A1 - Installing a cable in an underwater well installation - Google Patents
Installing a cable in an underwater well installation Download PDFInfo
- Publication number
- US20110297398A1 US20110297398A1 US13/152,706 US201113152706A US2011297398A1 US 20110297398 A1 US20110297398 A1 US 20110297398A1 US 201113152706 A US201113152706 A US 201113152706A US 2011297398 A1 US2011297398 A1 US 2011297398A1
- Authority
- US
- United States
- Prior art keywords
- cable
- passageway
- conduit
- fluid
- umbilical
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000009434 installation Methods 0.000 title claims abstract description 19
- 239000012530 fluid Substances 0.000 claims abstract description 30
- 238000000034 method Methods 0.000 claims abstract description 26
- 238000004519 manufacturing process Methods 0.000 claims description 5
- 239000004020 conductor Substances 0.000 claims description 3
- 239000000835 fiber Substances 0.000 claims description 3
- 238000006073 displacement reaction Methods 0.000 claims 1
- 238000004891 communication Methods 0.000 description 10
- 238000005086 pumping Methods 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 230000000153 supplemental effect Effects 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 239000004519 grease Substances 0.000 description 2
- 230000013011 mating Effects 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 238000013022 venting Methods 0.000 description 2
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical group [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000002144 chemical decomposition reaction Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 229920002994 synthetic fiber Polymers 0.000 description 1
Images
Classifications
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02G—INSTALLATION OF ELECTRIC CABLES OR LINES, OR OF COMBINED OPTICAL AND ELECTRIC CABLES OR LINES
- H02G1/00—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines
- H02G1/06—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle
- H02G1/08—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle through tubing or conduit, e.g. rod or draw wire for pushing or pulling
- H02G1/086—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle through tubing or conduit, e.g. rod or draw wire for pushing or pulling using fluid as pulling means, e.g. liquid, pressurised gas or suction means
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02G—INSTALLATION OF ELECTRIC CABLES OR LINES, OR OF COMBINED OPTICAL AND ELECTRIC CABLES OR LINES
- H02G1/00—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines
- H02G1/06—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle
- H02G1/10—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for laying cables, e.g. laying apparatus on vehicle in or under water
Definitions
- Embodiments of the present invention relate to installing a cable in an underwater well installation.
- umbilicals transmit power and fluid from a surface platform to a subsea fluid production facility. They typically have redundant or spare conduits for chemical and hydraulic control lines within them, originally intended for back-up purposes.
- U.S. Pat. No. 5,871,052 relates to downhole tool deployment techniques using mud pumping techniques and U.S. Pat. No. 5,967,816 relates to a female wet connector for use in such techniques.
- FIG. 1 shows schematically the topside end of a subsea hydrocarbon well installation
- FIG. 2 shows schematically the subsea end of the installation
- FIG. 3 is a detailed view of part of what is shown in FIG. 1 ;
- FIG. 4 is a detailed view of part of what is shown in FIG. 2 ;
- FIG. 5 shows schematically an alternative to what is shown in FIG. 2 .
- an insulated cable is “pumped down” a spare, back-up or in-use chemical or hydraulic control line conduit.
- the cable may have one, two (for a return path) or more cores and can be used to transmit electric power and/or data to and/or from a subsea production facility.
- a fibre-optic cable could also be in the cable to provide a replacement, or additional, communication link.
- the embodiments allow additional electric power and/or communications capability to a “Brownfield” site, or provide for additional electrical and/or communication facilities to an updated fluid production facility.
- a multiplicity of gas and/or fluid and/or chemical supply conduits 1 , 2 and 3 (three shown as an example only) and power and/or communication cables (not shown) within an umbilical 4 are terminated with connectors 5 .
- the connectors 5 are coupled with connectors 6 via respective ones of upper ducts 8 , which may be rigid ducts.
- Connectors 6 themselves mate with respective ones of connectors 61 at a topside umbilical termination unit (TUTU) 7 .
- TUTU topside umbilical termination unit
- Conduit 3 (which could, for example, be a spare or unused conduit in the umbilical 4 ) is chosen to receive a “pumped down” replacement or supplemental cable 9 .
- the respective duct 8 forms part of a “side-entry” sub-assembly 10 , which includes an arrangement 11 at duct 8 of conduit 3 that allows the cable 9 to enter but not fluid to escape.
- Fluid (either the normal fluid for conduit 3 or a special inert fluid if conduit 3 is a spare or unused conduit) is then pumped down the conduit 3 from the duct 8 of sub-assembly 10 in the direction of arrow 12 , towards a subsea facility, to carry cable 9 with it.
- a swab cup 13 is placed towards the end of cable 9 to help in this process.
- the cable 9 could comprise at least one electrical conductor for power and/or communications or it could comprise at least one fibre optic line for communication purposes or it could comprise at least one electrical conductor for power and/or communications and at least one fibre optic line.
- the cable 9 is terminated with a wet mateable connector 14 suitable for the function or functions of cable 9 .
- the swab cup 13 may be omitted if connector 14 is itself sufficient to assist in the “pumping down” of cable 9 .
- the sub-assembly 10 (which also comprises the rest of the ducts 8 and all the connectors 6 ) is effectively an extension of the umbilical 4 and its connectors 5 (which would otherwise mate with connectors 6 ) and is installed for the purpose of providing a side entry for inserting a cable, typically to extend the life of a “Brownfield” well.
- the umbilical 4 in the Figures is not to scale and is exaggerated in size compared to the sub-assembly 10 and TUTU 7 .
- spare or disused conduit 3 within the umbilical 4 is used, if the size of the cable 9 and its swab cup 13 and connector 14 are small enough compared with the diameter of the conduit 3 , then it could be a conduit which continues to be used for its normal function. Thus, pumping fluid down the conduit to transport the replacement or supplemental cable 9 may be part of normal operations or could be performed specifically for this task.
- an exit sub-assembly 15 is placed between the subsea end of the umbilical 4 and a subsea umbilical termination unit (SUTU) 16 .
- the sub-assembly 15 comprises, for each of connectors 17 at the subsea ends of the conduits in the umbilical 4 except conduit 3 used for “pumping down” the cable, a lower duct 18 (which may be rigid) terminating in a connector 19 which mates with a respective connector 191 of the SUTU 16 .
- the sub-assembly 15 comprises a lower duct 20 (which may be rigid) extending from the connector 17 of conduit 3 for expelling fluid from conduit 3 to the surrounding water and carrying at its lower end a wet mateable connector 21 providing connection to an external cable 22 to feed subsea devices such as at least one subsea control module (SCM).
- SCM subsea control module
- the wet mateable connector 21 allows fluid past it both before and after being mated with the connector 14 .
- FIGS. 3 and 4 show details of the topside side-entry and subsea cable exit arrangements.
- the cable 9 without swab cup 13 or the connector 14 is inserted through a sealing clamp 23 of arrangement 11 so that it protrudes through a connector port of the side-entry sub-assembly 10 .
- the swab cup 13 and the connector 14 are then assembled on the cable 9 .
- the clamp 23 which is around a packer 24 for example of felt or a synthetic material, is then tightened sufficiently to allow sliding of the cable 9 , yet provide a good seal resulting from the saturation of the material comprising the packer 24 with grease injected via a grease point 25 .
- the sub-assembly 10 is then fitted between the umbilical 4 and the TUTU 7 .
- the subsea side-exit assembly 15 is installed by a remotely operated vehicle. With fluid flow through the conduit 3 , the cable 9 is “pumped down” and the connector 14 is aligned with the mating connector 21 by a centraliser 26 for guiding the cable 9 and connector 21 , located just above the connector 21 in the side-exit sub-assembly 15 . There could be at least one farther such centraliser above centraliser 26 in the passageway comprising duct 8 , conduit 3 and duct 20 .
- the connector 14 carries a cylinder of spring fingers which clamp it to a spigot 27 on the connector 21 to lock them together.
- the configuration of the side-exit sub-assembly 15 shown allows venting of the pumped down fluid to the sea or its recovery.
- the side-exit assembly 15 can be configured to route the flow from the conduit carrying the cable 9 hack up another fluid conduit to the surface. This flow path may then be closed (during the wet mating of connector 14 with connector 21 ) to allow future use of the second fluid conduit.
- the side-exit assembly 15 provides electrical and/or optical break-outs from the wet mated connection to traditional jumpers for connection to an SCM or other device requiring power and/or communication.
- the side-entry and side-exit sub-assemblies may be for a single use or can be permanently in an installation or can be releasable and deployed for occasional operations.
- the connector 14 could be latched and locked on to connector 21 and spigot 27 for a permanent installation or include the ability to de-latch it if the operator wants to remove it. De-latching could be achieved by applying tension from the topside, although an operator could just remove the subsea side exit assembly 15 and cut the cable 9 .
- a supplemental or replacement cable may be “pumped up” from a subsea location to a topside location using production fluid.
- a cable may be “pumped down” via a passageway which comprises a line separate from the umbilical and carrying a fluid, such as a chemical or water and/or gas injection line.
- Embodiments of the present invention enable the avoidance of replacing a degraded umbilical for power and/or communication. Embodiments of the present invention also enable an increase in the amount of power available at an installation through an additional cable (field expansion or new equipment). Embodiments of the present invention further enable a second communication path for additional equipment.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Laying Of Electric Cables Or Lines Outside (AREA)
- Connector Housings Or Holding Contact Members (AREA)
Abstract
A method of installing a cable between a topside location of an underwater well installation and an underwater location of the installation is provided. The method comprises inserting an end of the cable into a passageway between the locations and using a fluid passed along the passageway to displace the cable along the passageway so that it extends between the locations.
Description
- 1. Field of the Invention
- Embodiments of the present invention relate to installing a cable in an underwater well installation.
- 2. Description of the Prior Art
- In subsea hydrocarbon well installations, umbilicals transmit power and fluid from a surface platform to a subsea fluid production facility. They typically have redundant or spare conduits for chemical and hydraulic control lines within them, originally intended for back-up purposes.
- Over time, the insulation around the copper cores of electrical cables in the umbilical may degrade, for example through water ingress or chemical degradation. The cores themselves may also degrade, typically through corrosion. Such degradation may result in a reduction in the electrical capacity of the cores so that inadequate power is available to the well installation which is then unable to function adequately. An alternative possibility is to update the well installation with additional facilities requiring additional power which is not available with the existing power distribution system. Currently, the only solution to these problems is to replace the umbilical, which is very expensive, although an alternative solution is taught in UK Patent Application No. 0921858.7.
- U.S. Pat. No. 5,871,052 relates to downhole tool deployment techniques using mud pumping techniques and U.S. Pat. No. 5,967,816 relates to a female wet connector for use in such techniques.
- According to one embodiment of the present invention, there is provided a method of installing a cable between a topside location of an underwater well installation and an underwater location of the installation, the method comprising inserting an end of the cable into a passageway between the locations and using a fluid passed along the passageway to displace the cable along the passageway so that it extends between said locations.
-
FIG. 1 shows schematically the topside end of a subsea hydrocarbon well installation; -
FIG. 2 shows schematically the subsea end of the installation; -
FIG. 3 is a detailed view of part of what is shown inFIG. 1 ; -
FIG. 4 is a detailed view of part of what is shown inFIG. 2 ; and -
FIG. 5 shows schematically an alternative to what is shown inFIG. 2 . - In the following embodiments, an insulated cable is “pumped down” a spare, back-up or in-use chemical or hydraulic control line conduit. The cable may have one, two (for a return path) or more cores and can be used to transmit electric power and/or data to and/or from a subsea production facility. A fibre-optic cable could also be in the cable to provide a replacement, or additional, communication link. The embodiments allow additional electric power and/or communications capability to a “Brownfield” site, or provide for additional electrical and/or communication facilities to an updated fluid production facility.
- Referring first to
FIG. 1 , at the surface of a subsea hydrocarbon well installation, a multiplicity of gas and/or fluid and/orchemical supply conduits connectors 5. Theconnectors 5 are coupled withconnectors 6 via respective ones ofupper ducts 8, which may be rigid ducts.Connectors 6 themselves mate with respective ones ofconnectors 61 at a topside umbilical termination unit (TUTU) 7. - Conduit 3 (which could, for example, be a spare or unused conduit in the umbilical 4) is chosen to receive a “pumped down” replacement or
supplemental cable 9. For the chosenconduit 3, therespective duct 8 forms part of a “side-entry” sub-assembly 10, which includes anarrangement 11 atduct 8 ofconduit 3 that allows thecable 9 to enter but not fluid to escape. Fluid (either the normal fluid forconduit 3 or a special inert fluid ifconduit 3 is a spare or unused conduit) is then pumped down theconduit 3 from theduct 8 of sub-assembly 10 in the direction ofarrow 12, towards a subsea facility, to carrycable 9 with it. Aswab cup 13 is placed towards the end ofcable 9 to help in this process. Thecable 9 could comprise at least one electrical conductor for power and/or communications or it could comprise at least one fibre optic line for communication purposes or it could comprise at least one electrical conductor for power and/or communications and at least one fibre optic line. Thecable 9 is terminated with a wetmateable connector 14 suitable for the function or functions ofcable 9. Theswab cup 13 may be omitted ifconnector 14 is itself sufficient to assist in the “pumping down” ofcable 9. - It should be noted that the sub-assembly 10 (which also comprises the rest of the
ducts 8 and all the connectors 6) is effectively an extension of theumbilical 4 and its connectors 5 (which would otherwise mate with connectors 6) and is installed for the purpose of providing a side entry for inserting a cable, typically to extend the life of a “Brownfield” well. It should also be noted that the umbilical 4 in the Figures is not to scale and is exaggerated in size compared to the sub-assembly 10 and TUTU 7. - Although in this embodiment spare or
disused conduit 3 within the umbilical 4 is used, if the size of thecable 9 and itsswab cup 13 andconnector 14 are small enough compared with the diameter of theconduit 3, then it could be a conduit which continues to be used for its normal function. Thus, pumping fluid down the conduit to transport the replacement orsupplemental cable 9 may be part of normal operations or could be performed specifically for this task. - As shown diagrammatically in
FIG. 2 , anexit sub-assembly 15 is placed between the subsea end of the umbilical 4 and a subsea umbilical termination unit (SUTU) 16. Thesub-assembly 15 comprises, for each ofconnectors 17 at the subsea ends of the conduits in theumbilical 4 exceptconduit 3 used for “pumping down” the cable, a lower duct 18 (which may be rigid) terminating in aconnector 19 which mates with arespective connector 191 of the SUTU 16. Also, thesub-assembly 15 comprises a lower duct 20 (which may be rigid) extending from theconnector 17 ofconduit 3 for expelling fluid fromconduit 3 to the surrounding water and carrying at its lower end a wetmateable connector 21 providing connection to anexternal cable 22 to feed subsea devices such as at least one subsea control module (SCM). The wetmateable connector 21 allows fluid past it both before and after being mated with theconnector 14. - The mode of operation for installing
cable 9 in theconduit 3 within the umbilical 4 is as follows.FIGS. 3 and 4 show details of the topside side-entry and subsea cable exit arrangements. Before the side entry sub-assembly 10 is installed between the umbilical 4 and theTUTU 7, thecable 9 withoutswab cup 13 or theconnector 14 is inserted through asealing clamp 23 ofarrangement 11 so that it protrudes through a connector port of the side-entry sub-assembly 10. Theswab cup 13 and theconnector 14 are then assembled on thecable 9. Theclamp 23, which is around apacker 24 for example of felt or a synthetic material, is then tightened sufficiently to allow sliding of thecable 9, yet provide a good seal resulting from the saturation of the material comprising thepacker 24 with grease injected via agrease point 25. The sub-assembly 10 is then fitted between the umbilical 4 and the TUTU 7. - The subsea side-
exit assembly 15 is installed by a remotely operated vehicle. With fluid flow through theconduit 3, thecable 9 is “pumped down” and theconnector 14 is aligned with themating connector 21 by acentraliser 26 for guiding thecable 9 andconnector 21, located just above theconnector 21 in the side-exit sub-assembly 15. There could be at least one farther such centraliser abovecentraliser 26 in thepassageway comprising duct 8,conduit 3 andduct 20. Theconnector 14 carries a cylinder of spring fingers which clamp it to aspigot 27 on theconnector 21 to lock them together. The configuration of the side-exit sub-assembly 15 shown allows venting of the pumped down fluid to the sea or its recovery. Alternatively, it can be configured to connect to the SUTU 16 to allow continued use of theconduit 3 for fluid flow, as shown byFIG. 5 . Other arrangements include the venting of the pumped down fluid during installation of thecable 9 and then closing the vent to allow continued use of the conduit for fluid flow. If multiple spare fluid conduits are free, then the side-exit assembly 15 can be configured to route the flow from the conduit carrying thecable 9 hack up another fluid conduit to the surface. This flow path may then be closed (during the wet mating ofconnector 14 with connector 21) to allow future use of the second fluid conduit. Thus, the side-exit assembly 15 provides electrical and/or optical break-outs from the wet mated connection to traditional jumpers for connection to an SCM or other device requiring power and/or communication. - The side-entry and side-exit sub-assemblies may be for a single use or can be permanently in an installation or can be releasable and deployed for occasional operations. For example, the
connector 14 could be latched and locked on toconnector 21 andspigot 27 for a permanent installation or include the ability to de-latch it if the operator wants to remove it. De-latching could be achieved by applying tension from the topside, although an operator could just remove the subseaside exit assembly 15 and cut thecable 9. - In one embodiment of the present invention a supplemental or replacement cable may be “pumped up” from a subsea location to a topside location using production fluid.
- In a further embodiment of the present invention, a cable may be “pumped down” via a passageway which comprises a line separate from the umbilical and carrying a fluid, such as a chemical or water and/or gas injection line.
- Embodiments of the present invention enable the avoidance of replacing a degraded umbilical for power and/or communication. Embodiments of the present invention also enable an increase in the amount of power available at an installation through an additional cable (field expansion or new equipment). Embodiments of the present invention further enable a second communication path for additional equipment.
Claims (17)
1. A method of installing a cable between a topside location of an underwater well installation and an underwater location of the installation, the method comprising inserting an end of the cable into a passageway between the locations and using a fluid passed along the passageway to displace the cable along the passageway so that it extends between said locations.
2. A method according to claim 1 , wherein said passageway comprises a conduit in an umbilical between said locations.
3. A method according to claim 2 , wherein said conduit comprises a spare or unused conduit in said umbilical.
4. A method according to claim 2 , wherein said conduit comprises one used in operation of the well installation.
5. A method according to claim 2 , wherein said umbilical is coupled at one, upper end to a topside umbilical termination unit.
6. A method according to claim 5 , wherein at said upper end, said conduit is coupled to said topside umbilical termination unit via an upper duct providing part of said passageway and into which said cable is inserted.
7. A method according to claim 2 , wherein, at an opposite, lower end of said umbilical, said conduit communicates with a lower duct providing part of said passageway.
8. A method according to claim 7 , wherein said fluid is expelled or recovered from said lower duct.
9. A method according to claim 7 , wherein said lower duct is coupled with an underwater umbilical termination unit.
10. A method according to claim 7 , wherein there is a connector in said lower duct with which an opposite end of said cable couples.
11. A method according to claim 10 , wherein said connector communicates externally of said lower duct.
12. A method according to claim 1 , wherein said passageway is provided with means for guiding said cable in said passageway.
13. A method according to claim 12 , wherein, at an opposite, lower end of said umbilical, said conduit communicates with a lower duct providing part of said passageway and wherein said guiding means is in said lower duct.
14. A method according to claim 1 , wherein said cable carries means against which said fluid acts to assist displacement of the cable by said fluid.
15. A method according to claim 1 , wherein said cable includes at least one electrical conductor and/or at least one fibre optic line.
16. A method according to claim 1 , wherein said cable is displaced from said underwater location to said topside location, said fluid being production fluid.
17. A method according to claim 1 , wherein said passageway comprises a line between said locations carrying a fluid.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP10165282A EP2395618A1 (en) | 2010-06-08 | 2010-06-08 | Installing a cable in an underwater well installation |
EP10165282.4 | 2010-06-08 |
Publications (1)
Publication Number | Publication Date |
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US20110297398A1 true US20110297398A1 (en) | 2011-12-08 |
Family
ID=43067198
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/152,706 Abandoned US20110297398A1 (en) | 2010-06-08 | 2011-06-03 | Installing a cable in an underwater well installation |
Country Status (7)
Country | Link |
---|---|
US (1) | US20110297398A1 (en) |
EP (1) | EP2395618A1 (en) |
CN (1) | CN102364795A (en) |
AU (1) | AU2011202687A1 (en) |
BR (1) | BRPI1102894A2 (en) |
MY (1) | MY184962A (en) |
SG (1) | SG177072A1 (en) |
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-
2010
- 2010-06-08 EP EP10165282A patent/EP2395618A1/en not_active Withdrawn
-
2011
- 2011-06-01 MY MYPI2011002493A patent/MY184962A/en unknown
- 2011-06-02 SG SG2011040490A patent/SG177072A1/en unknown
- 2011-06-03 US US13/152,706 patent/US20110297398A1/en not_active Abandoned
- 2011-06-06 AU AU2011202687A patent/AU2011202687A1/en not_active Abandoned
- 2011-06-07 BR BRPI1102894-7A patent/BRPI1102894A2/en not_active Application Discontinuation
- 2011-06-08 CN CN2011101670613A patent/CN102364795A/en active Pending
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Also Published As
Publication number | Publication date |
---|---|
BRPI1102894A2 (en) | 2013-03-19 |
EP2395618A1 (en) | 2011-12-14 |
CN102364795A (en) | 2012-02-29 |
MY184962A (en) | 2021-04-30 |
AU2011202687A1 (en) | 2011-12-22 |
SG177072A1 (en) | 2012-01-30 |
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